|Publication number||US7904248 B2|
|Application number||US 12/483,791|
|Publication date||Mar 8, 2011|
|Filing date||Jun 12, 2009|
|Priority date||Jul 1, 2004|
|Also published as||CA2572449A1, CA2572449C, EP1766439A2, US7742875, US20070219724, US20090248378, WO2006007466A2, WO2006007466A3|
|Publication number||12483791, 483791, US 7904248 B2, US 7904248B2, US-B2-7904248, US7904248 B2, US7904248B2|
|Inventors||Dachang Li, Tao Sun, Chun Huh, Chris J. Donofrio, Max Deffenbaugh, John C. Van Wagoner|
|Original Assignee||Exxonmobil Upstream Research Co.|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (27), Non-Patent Citations (18), Referenced by (10), Classifications (9), Legal Events (1)|
|External Links: USPTO, USPTO Assignment, Espacenet|
This application is a division of U.S. patent application Ser. No. 11/629,822 filed on Dec. 15, 2006, now U.S. Pat. No. 7,742,875 which is the National Stage of International Application No. PCT/US05/21991 filed on 24 Jun. 2005, which in turn claims the benefit of U.S. Provisional Application No. 60/584,617 filed on Jul. 1, 2004.
This invention relates generally to the fields of geophysical prospecting and reservoir characterization. More specifically, the invention is a method for creating geologic models permitting enhanced representation of the properties of a subsurface volume, such as a reservoir or basin.
A geologic model is a computer-based representation of a subsurface earth volume, such as a petroleum reservoir or a depositional basin. In the oil and gas industry, geologic models are commonly used in activities such as determining the locations of wells, estimating hydrocarbon reserves, or planning reservoir-development strategies. Geologic models are also input to fluid flow simulations to test development and production scenarios in order to optimize return on investment. A key parameter in flow simulation is the spatial distribution of permeability, which together with the properties of the hydrocarbons and other fluid found in the subsurface reservoir, determines the producibility of the reservoir. Typically, the input data for geologic models includes data obtained through seismic prospecting techniques.
Seismic prospecting techniques are commonly used to aid in the search for and evaluation of subterranean hydrocarbon reservoirs. A seismic prospecting operation consists of three separate stages: data acquisition, data processing, and data interpretation. The success of the operation depends on satisfactory completion of all three stages.
In the data acquisition stage, a seismic source is used to generate an acoustic signal that propagates into the earth and is at least partially reflected by subsurface seismic reflectors. The reflected signals are detected and recorded by an array of seismic receivers located at or near the surface of the earth, in an overlying body of water, or at known depths in boreholes.
During the data processing stage, the recorded seismic signals are refined and enhanced using a variety of procedures that depend on the nature of the geologic structure being investigated and on the characteristics of the raw data. In general, the purpose of the data processing stage is to produce an image of the subsurface from the recorded seismic data for use during the data interpretation stage.
The purpose of the data interpretation stage is to determine information about the subsurface geology of the earth from the processed seismic data. The results of the data interpretation stage may be used to determine the general geologic structure of a subsurface region, or to locate potential hydrocarbon reservoirs, or to guide the development of an already discovered reservoir.
At present, the conclusions, which can be made after the data interpretation stage, are generally limited to broad descriptions of the size and general nature of subsurface structures due to the limited resolution of seismic data. The descriptions may for example provide an indication of the total volume of hydrocarbons, which might be retained in such structures. However, present technology does not allow the analyst to determine production rates from the subsurface formations if hydrocarbons are discovered. In addition, when an exploration well has been drilled, present technology does not allow an analyst to be able to accurately characterize the nature of the subsurface internal geometry in locations other than in the most immediate region of any such well. In particular, reservoir permeability and continuity are not well characterized by present technology.
The hydrocarbon volume and rate of production depend on a variety of factors, including fluid properties, reservoir net-to-gross, porosity, permeability, spatial variability in grain size distribution, and connectivity. Reservoir connectivity, a measure of the communication (or lack thereof) between points within the reservoir, is a strong function of the reservoir internal geometry and is commonly a primary factor controlling hydrocarbon production efficiency and ultimate recovery. There is a need to predict the detailed internal geometry of subsurface reservoirs using geologic data, such as seismic data, and without having to drill many exploration and delineation wells. Such a capability would facilitate estimation of hydrocarbon volume in place and production rates early in the hydrocarbon exploration and development process.
Another step in geologic modeling is “gridding.” Gridding is the division of the subsurface region into cells, within which the rock properties are regarded as uniform. The ability to accurately model reservoir internal geometry and connectivity is largely dependent on the vertical grids used in the modeling processes due to the nature of stratification and vertical heterogeneity in the reservoir. As a result, the gridding methods in geologic modeling focus mainly on the vertical variation of attributes of a geologic model. In map view, uniform rectangular grids are commonly used for relatively small variations of attributes in the lateral directions.
There are four gridding methods commonly used in commercially available geologic modeling tools. Examples of commercially available geologic modeling tools include: SGM (Landmark Graphics Corporation, Stratamodel Geocellular Modeling (SGM), 1989-2003), RMS (Roxar ASA, Irap RMS (Reservoir Modeling Systems), 1993-2003), gOcad (Earth Decision Sciences Corporation, gOcad, 1989-2003), and Petrel (Technoguide (A Schlumberger Product Group), Petrel™ Workflow Tools, 1996-2003). The four gridding methods used in the petroleum industry are commonly named proportional, onlap, truncation, and reference. The name of each method can vary from one tool to another. For example, “reference-grid” in RMS is the same as “depositional-grid” in SGM. The choice of the most appropriate gridding method to use when building a geologic model depends on the geologic modeler's experience and personal judgement of the model's particular geologic setting. Gridding style, however, was created to mimic natural patterns of erosion and deposition observed in nature at the seismic scale.
The gridding methods used in the most commercially available geologic modeling tools (such as, SGM, RMS, gOcad, and Petrel) are based on methods disclosed in two of Swanson's patents. The patents are U.S. Pat. Nos. 4,821,164 and 4,991,095.
As shown in
As shown in
As shown in
As shown in
The problem is that none of these gridding methods represent the true internal geometry accurately. To illustrate this problem, there are five disconnected sand bodies 1, 2, 3, 4, and 5 within the sequence 11 of
Some sand bodies are incorrectly disconnected within themselves. For example, sand body 4 is disconnected in the proportional-grids of
The grids constructed by the above-mentioned prior art methods do not properly align themselves with the reservoir internal geometry. The alignment between the grids and the reservoir internal geometry is important for two reasons. First, any lack of alignment distorts the reservoir connectivity in the geologic model subsequently built. Second, when the geologic model is scaled up for reservoir performance simulation with coarser grids, the coarser grids will magnify the misrepresentations and distortions that exist in the geologic model. Consequently, the accuracy of any reservoir performance prediction will decrease, which will hamper reservoir management.
A reliable reservoir performance simulation depends strongly on the ability of a geologic model to accurately characterize the spatial distribution of permeability. Most important are the permeability extremes, such as high-permeability sand bodies and no-flow shale barriers, because the permeability extremes typically control the oil, gas, and water flows. The ability to model permeability is currently severely limited by the commercially available geologic model gridding methods. One reason that the existing geologic modeling tools have to adopt arbitrary lateral grid surfaces is that the actual strata geometry (or layering) of the sand objects is not known a priori. As a consequence, the reservoir connectivity is typically misrepresented in geologic models and the resulting performance simulation models. Accordingly, there is a need for a method that generates grids that follow the geometry of sand bodies and shale barriers. Preferably, these grids would allow the reservoir connectivity to be accurately characterized in a geologic model and preserved during upscaling for reservoir performance simulation. The current invention addresses the need by generating the lateral grid surfaces naturally, following the complex depositional and erosional processes observed in nature.
Under the present techniques, various embodiments of a hydrodynamics-based gridding method, called “Hydro-Grids”, may generate grid surfaces conforming to time surfaces during the process of sedimentation, which create a subsurface sedimentary volume. The location of these time surfaces is typically determined by sedimentary process simulation and interpretation of geologic data. Since these surfaces can precisely follow the geometry of sand bodies and shale barriers, geologic models conforming to these surfaces may accurately characterize sedimentary connectivity and may preserve their accuracy during upscaling for reservoir performance simulation.
A method for geologic modeling of a subsurface volume, such as a geologic basin or reservoir, is disclosed. The method includes obtaining geologic data, creating vertical grid surfaces, creating lateral grid surfaces to correspond with surfaces of constant geologic time during the deposition of sediments in the subsurface volume, and representing the geologic properties of the subsurface volume as values in each cell created by the vertical grid surfaces and the lateral grid surfaces. The method also includes simulating reservoir performance using the represented geologic properties of the subsurface volume, and developing a hydrocarbon reservoir based on the simulated reservoir performance.
According to the disclosed aspects and methodologies, the geologic data used may include, but is not limited to, seismic data, outcrop studies, well log data, core data, data from numerical modeling of geological processes, stratigraphic surfaces interpreted from seismic data, and any combination thereof. The modeled geologic properties of the reservoir may include, but are not limited to, grain size distribution, connectivity, net-to-gross, porosity, permeability, pore pressure and any combination thereof. The vertical grid surfaces partition the subsurface volume into regions based on lateral variation of geologic properties. The partitioning of the regions may be configured to have large bins for little lateral variation in geologic properties and small bins for large lateral variation in geologic properties. At least one of the lateral grid surfaces may be adjusted to match the geologic data. At least one of the lateral grid surfaces may be adjusted to account for the removal of sediment by erosion subsequent to deposition. The lateral grid surfaces may be determined by numerical simulation of sedimentary processes based on the geologic data.
A second embodiment for geologic modeling of a subsurface volume is disclosed. This embodiment comprises obtaining geologic data, creating vertical grid surfaces, creating lateral grid surfaces to correspond with surfaces of constant geologic time during deposition or creation of geologic structures such as sediments in the subsurface volume, representing the geologic properties of the subsurface volume as values in each cell created by the intersections of the vertical grid surfaces and the lateral grid surfaces, merging selected grid cells, and calculating geologic property values in the merged grid cells. The method also includes simulating reservoir performance using the calculated geologic property values.
Aspects of the disclosed methodologies and techniques may also include merging selected grid cells and calculating geologic properties therefor until each of the desired grid cells are merged. Grid cells may be selected for merging based on criteria including at least one of a classification of a common grid surface in a stratigraphic hierarchy system, grid cells having substantially equal geologic property values, one of the grid cells having a thickness less than a threshold value, the grid cells merging with minimum swept efficiency errors, and flow properties during their deposition having been about equivalent. The geologic data may include at least one of seismic data, outcrop study data, well log data, core data, numerical modeling data, stratigraphic surfaces interpreted from seismic data, and any combination thereof. The vertical grid surfaces may partition the subsurface volume into regions based on geologic properties of layers. Partitioning of the regions may be configured to have large bins for little lateral variation in geologic properties and small bins for large lateral variation in geologic properties. Sedimentary properties of the subsurface volume may be selected from at least one of grain size distribution, connectivity, net-to-gross, porosity, permeability, pore pressure, and any combination thereof. At least one of the lateral grid surfaces may be adjusted to match the geologic data, which may include adjusting at least one of the lateral grid surfaces to favorably correspond to seismic reflection horizons. The lateral grid surfaces may be determined by numerical simulation of sedimentary processes based on the geologic data. At least one of the lateral grid surfaces may be adjusted to account for removal of sediment by erosion subsequent to deposition. A hydrocarbon reservoir may be developed based on the simulated reservoir performance. At least one original horizontal grid line may be created by estimating the deposition rate without erosion and the erosional effects are reconciled by adjusting at least one horizontal grid line to match the sedimentary data.
In the following detailed description, the invention will be described in connection with its preferred embodiments. However, to the extent that the following description is specific to a particular embodiment or a particular use, this is intended to be illustrative only. Accordingly, the invention is not limited to the specific embodiments described below, but rather the intent is to include all alternatives, modifications, and equivalents falling within the true scope of the appended claims.
Hydro-Grids are grids created by sedimentary process simulation. The Hydro-Grids lateral or horizontal surfaces, which may include and be represented by grid lines, are time surfaces recorded during the simulation of sand deposition/erosion. The grid surfaces follow the sand body shapes and their internal architecture (structure) naturally without any assumptions used by the existing geologic model gridding methods. Therefore, the sand body shapes and their internal structure can be precisely maintained for reservoir performance simulation.
As shown in
Now referring to numeral 21 in
Now referring to numeral 22 in
Now referring to numeral 23 in
Determining the lateral grid surfaces (lines) typically includes various steps. First, a basal surface for a subvolume within the subsurface volume is determined from seismic data. This is accomplished by a skilled seismic interpreter according to methods familiar to persons of ordinary skill in the art. Second, the basal surface is adjusted to correct its dip and orientation to the original position of the surface at the time of deposition. Depending on the nature and degree of post-depositional change, this may include a rotation of the surface to restore the paleoslope and unbending the surface to remove the effect of subsidence. The size and degree of these adjustments is determined according to the judgement of skilled interpreters as will be understood by persons of ordinary skill in the art. Computer simulation of subsidence and other post-depositional processes may assist in this determination (e.g., Bezemer, T. D., Kooi, H., and Cloetingh: “Numerical Modeling of Fault-Related Sedimentation,” SEPM Special Publications No. 62, Numerical Experiments in Stratigraphy: Recent Advances in Stratigraphic and Sedimentologic Computer Simulations, SEPM (Society for Sedimentary Geology) 1999). Third, a numerical simulation of the sedimentary processes, which may fill the subsurface volume, is performed over the adjusted basal surface. Such simulations run forward in geologic time, computing the amount and nature of sediment deposited at each location at each time step. The top surfaces of the simulated deposit are recorded at regular time steps. The number of layers in the geologic model may be controlled by changing the time step size. Alternatively, the top surfaces may be recorded only at time steps when a significant change in deposition rate or deposited sediment properties occurs. These steps may be iterated to adjust the boundary conditions of the simulation until good correspondence is achieved between the simulated deposit and the geologic data. Finally, if transformations were applied to the basal surface prior to simulation, the reverse of these transformations are applied to the basal surface and all computed top surfaces, so that the surfaces are moved to their likely present-day position.
If, during the simulation, the flow is near steady state and predominantly depositional, the deposit composition is vertically homogeneous, and lateral grid surfaces may be separated by an extended period of simulation time. However, if the flow is highly transient with significant avulsions, the lateral grid surfaces may be defined at much smaller time intervals. This non-uniform-layering method ensures that the rock properties are as homogeneous as possible within a layer, which effectively characterizes reservoir connectivity.
During and after the simulation for a particular subvolume, there are several adjustments that are typically made to the lateral grid surfaces (lines). First, the vertical coordinates of a lateral grid surface (line) may be adjusted to account for any removal of sediment by erosion after the original sediment in the layer is deposited. Otherwise the lateral grid surfaces (lines) may cross each other, which is not permitted. Second, it may be found that certain lateral grid surfaces (lines) created in simulation may not match in location the corresponding actual surfaces observed in seismic data, well logs, or other forms of geologic data as described in numeral 21 of
Now referring to numeral 24 in
An example of Hydro-Grids is shown in
As shown in
Now referring to numeral 41 in
For the reference numerals 42, 43 and 44, these steps may be similar to the steps discussed in
Now referring to numeral 45 of
A first approach to merging the cells may include deposit property changes. The deposit property changes include determining the degree of change in the geologic properties across the cell boundary to determine whether the cells may be merged. Typically, a threshold of acceptable change is selected, and cells are merged for cells that have changes less than the threshold value.
A second approach to merging the cells may include a swept efficiency error (a combination effect of permeability, porosity, and other rock properties). A layer optimization technique can be used to determine the optimal layer-grouping schemes that minimize the errors of swept efficiency between the merged and original layers (cells). Layer optimization is a mature technology that is known to persons skilled in the art and can be found in a number of publications. Examples of publications that disclose layer optimization include Stern, D. and Dawson, A. G.: “A Technique for Generating Reservoir Simulation Grids to Preserve Geologic Heterogeneity,” paper SPE 51942 presented at the 1999 SPE Reservoir Simulation Symposium held in Houston, Tex., 14-17 Feb., 1999; and Li, D. and Beckner, B.: “Optimal Uplayering for Scaleup of Multimillion-Cell Geologic Models,” paper SPE 62927 presented at the 2000 SPE Annual Technical Conference and Exhibition held in Dallas, Tex., 1-4 Oct., 2000.
A third approach to merging the cells may include minimum thickness criteria. Minimum thickness criteria utilizes the thickness of the layers between lateral surfaces. Typically, a wide range in the thickness of the layers between lateral surfaces. Thin layers are generated near the edges of sand body lobes or where fine-grain sediments are deposited, with a sedimentary process simulation. Thick layers are generated near the lobe/channel centers or where coarse-grain sediments are deposited. Particularly very thin cells may cause numerical problems in reservoir performance simulation. A minimum thickness threshold is typically used to truncate very thin cells. If a cell is judged to be too thin, it may be assigned zero thickness and its actual thickness added to the cell above or the cell below, depending on which cell is closer in geological properties to the thin cell. The process is preferably continued until the thickness of the cells either exceeds the given threshold thickness or is equal to about zero. After merging the neighboring layers, some of layers may have zero thickness in some regions. Most reservoir performance simulators automatically treat the zero thickness cells as inactive cells. For example, Eclipse, a product of Schlumberger, is an example of a commercially available reservoir performance simulator that is known to persons skilled in the art.
A fourth approach to merging the cells may be stratigraphic hierarchy. Stratigraphic hierarchy includes associating the lateral surfaces between cells with particular levels in the stratigraphic hierarchy familiar to stratigraphers. This hierarchy uses classifications such as “lamina”, “laminaset”, “bed”, and “bedset”. Cells that share surfaces below a certain level in this hierarchy may be merged. For example, bed-scale and higher surfaces may be retained, while lamina and laminaset surfaces are removed. This hierarchy and the criteria for determining which level applies to a particular surface are described in Lamina, Laminaset, Bed and Bedset. See Campbell, C. V., Lamina, Laminaset, Bed and Bedset, Sedimentology, vol. 8 at 7-26 (1967). A lamina is the smallest megascopic layer that forms very rapidly from minutes to hours. A laminaset is a relative conformable succession of genetically related laminae bounded by surfaces of erosion, non-deposition or their correlative conformities, which forms rapidly from minutes to days. A bed is a relative conformable succession of genetically related laminae and laminasets bounded by surfaces (referred to as bedding surfaces) of erosion, non-deposition or their correlative conformities, which forms rapidly from minutes to years. A bedset is a group or set of conformable beds that differ in composition, texture, or sedimentary structure from those composing the beds above or below the bedset. Bedsets form over a longer period of time than beds. The stratigraphic hierarchy levels are associated with the corresponding levels of the changes of flow conditions. Avulsions and/or new inlet locations may create a high level of the hierarchy. Progradation, aggradation, and retrogradation may result in an intermediate level of the hierarchy and waves may generate a low level of the hierarchy. The stratigraphic hierarchy levels may be determined from the levels of the changes in the simulation conditions or from the inspection of the vertical distribution of the composition of the simulated deposit based on geologist's experience, as is conventionally done. The hierarchy levels assigned can be adjusted to achieve a favorable correlation with the cores, well logs, and seismic data.
In one embodiment, once it is established that two cells may be merged, one of the two cells is assigned “zero” thickness and the other cell is assigned the combined thickness of the two cells. If a lateral surface contacts at least one cell of zero thickness at every mapview location, then it can be removed. When merging two cells, the choice of which cell gets zero thickness is guided by the goal of removing as many lateral surfaces or regions as possible.
Now referring to numeral 46 of
The Hydro-Grids idea can also be used in many commercially available sedimentary process simulators.
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|U.S. Classification||702/12, 702/16, 702/5|
|Cooperative Classification||G01V2210/661, G01V1/282, G01V1/306|
|European Classification||G01V1/28B, G01V1/30D|